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![LAB ANALYSIS
Modified SARA [IP 143/90 (ASTM D-3279-90)] - SPE-165912
CII is more than 0.9, instability is
indicated. If it is less than 0.7, the
crudes are generally stable.](https://image.slidesharecdn.com/deleumwax-scaleremovalinjection-250223091022-4521bec1/75/deleum_Wax-scale-removal-injection-company-9-2048.jpg)
deleum_Wax-scale removal injection company
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- 3. FLOW ASSURANCE ▪ Pipelinecleaning ▪ Modular pumping service ▪ Well integrity ▪ Online/offline cleaning of process equipment(i.e. Heat exchangers, boilers, separators) ▪ Water injection system PRODUCTION ENHANCEMENT ▪ Well stimulation / matrix acidization ▪ Wettability change ▪ Kinematic viscosity improvement ▪ Tubing clean-up ▪ Chemical Enhanced Oil Recovery (CEOR) RESEARCH & DEVELOPMENT ▪ Well sample analysis & diagnostic ▪ Bespoke chemical to suit each condition ▪ Chemical mapping as per region OPTIMIZATION PLAN ▪ Analysis on production trend and skin factor ▪ Re-treatment planning to optimize production & cost OUR SERVICES 02
- 4. PROBLEM STATEMENT ❖ Paraffinand Asphaltene formation • High contentof saturates,aromatics, asphalteneand resin togetherwith napthenatecan lead to this causesif its not treated/takencare • High molecular paraffin which is known as micro –crystallinewax will start to form and due to nucleatingagent ❖ High WAT and Pour Point • Crude start to get viscousand congealat a pointand loosesit flowing ability • Frictionof flow will allow the settlingtime for the wax to form slowly and be on crystalform. Result in high DP.
- 5. PROBLEM STATEMENT ❖ Pipeline •Pipelinedesignitself might contributeto this kind of congealing crude due to no improperinsulationand heat loss prevention ❖ Crude Character • Crude character to be studiedwith extendedSARA analysisto identifythe hydrocarbonschain and the severityof it • SARA analysis and dissolutiontest will result in the bestsolution selection ❖ Congeal crude might get coated with Scale • The congealcrude will becomeevenharder if its coatedwith water which eventuallybecomescales(embeddedtype deposition)due to naphthenicacid and water which will cause hard wax layer
- 6. Current Scenario inPipeline ❖Could be interval choke ❖Could be fully choked(not possibleif the line is currently onlinemeans) ❖Could be partially chokedas per geometry of pipelineand temperatureelevation
- 7. Current Scenario inPipeline ❖Could be interval choke ❖Could be fully choked(not applicableif there is communicationat the end) ❖Could be partially chokedas per geometry of pipelineand temperatureelevation
- 8. Producer problems Problem Statement• Inflow performance • Due to HUD or tubing choke • Restrict the flow path • Increasein ΔP • Outflow performance • Emulsion near wellbore • High molecular deposition near wellbore • Skin build up Type Method Mechanical Wax Scrubber / cutting Pigging Thermal Steam Injection Hot oil Water circulation Chemical Solvent/ surfactants Acidization
- 9. LAB ANALYSIS Modified SARA[IP 143/90 (ASTM D-3279-90)] - SPE-165912 CII is more than 0.9, instability is indicated. If it is less than 0.7, the crudes are generally stable.
- 10. Methodology and diagnosis ❖Crude and sample collection • SARA analysis will be conducted to identify all the possiblehydrocarbons • WAT (ASTM) • Pour PointAnalysis (ASTM) • SARA will indicatethe CII index and the tendency of the precipitation of wax at elevated temperature • Hydrocarbonsfractions in SARA will assiston the perfect chemical solution • Compatibilitytest and also temperature design • Dissolution test to identifythe chemical vs deposit
- 11. Exothermic Solution™ Unique Features Application Method Dissolution & Dispersion • Theonly Thermo-ChemicalTechnique in the Market fortreatment of waxy deposition. • Two pack system designed to generate in-situ heat (exothermic reaction). • CustomizeHeat Range: 125°C – 175°C. • Applied in more than 100 wells mainly in Malaysia, Indonesia and Thailand • Sections: Around wellbore, production tubing and surfacefacilities (refinery). • Clients : Petronas Carigali, Exxonmobill, Petrochina, PT.Odira, Petrofac, EnQuest, Chevron Duri, Premier Oil, Montdor Oil A B Heat 125°C - 175°C Novel Thermo-Chemical In-Situ Heat Generating Technique for organic deposit treatment/ removal (SPE 93844, OTC-23933, SPE-165912, SPE-107663, PETROTECH 2005, IPTC-17729)
- 12. APPLICATION METHOD Deposit 1 - Pre-flush -Active chemical - Post-flush Soaking 2 - 8 hours+ 3 Flow the well - Mixed chemical & dispersed deposit Chemical Treatment Application • formulations to dissolve and disperse deposit Diagnosis • Data analysis & Wellflow modeling • Lab analysis/characterization
- 13. Exothermic Chemical Sample inExothermic sample after 8HOURS soaking sample after 21DAYS soaking
- 14. DEL-SOLVE-Exothermic3™ ❖ One singlepack is required ❖ Replaces acidizing for near wellbore remediation ❖ Deposit specific – custom blended ❖ Work at ambient temperature ❖ Short soaking time - 8 hours++ ❖ Organic based – compatible with crude ❖ Dissolve/disperse napthenate solids ❖ Improves wettability ❖ Cleans flow line during flow back Napthenates are formed by interaction Oil Water ❖ Insoluble in both oil and water ❖ Very sticky ❖ Ash forming ❖ Do not respond to solvent or ❖ water bound formulations Naphtenate (Plastic wax) Techno- commercial benefits Well Baram 8S Oil production (bopd) Before treatment 268 After Treatment 450 Before After
- 15. FLOW ASSURANCE One-step formulationcapableofdissolvinginorganicdepositionand simultaneouslydissolve/ disperse organicdepositspresent.This customized formulation has the abilityto scavenge H2Sand mitigate the riskof H2S. Specialty formulation to remove pipeline scale where H2S is a potential hazard require permanent and instantaneous elimination and control.
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- 18. ▪ 10” effluentpipe (2 lines) ± 4.2km ▪ 50% choking ▪ 4 vendors tried and failed ▪ 65% inorganic (calcite & Iron Sulphide) ▪ Presence of H2S ▪ Line #1 ▪ Del-Scale: 1,635 bbl ▪ H2S Scav: 25 bbl ▪ Line #2 ▪ Del-PIRO: 2,641 bbl ▪ H2S Scav: 25 bbl 95%Scale removed 03 CASE #5 – TCOT PIPELINE CLEANING (Sept 2014)
- 19. ▪ Marmo #1, Jabung ▪ Well died 2009 and idle till 2015 (treatment date) ▪ High mol. weight wax 53% ▪ CII: 2.31 ▪ Dissolution tested ▪ 1 year of tech discussion ▪ Bullhead Del-Exo ▪ 86.7bbl ROI On the 5th day 03 – IDLE WELL REACTIVATION (INT) (Jan, 2015) $X,000,000.00 Generated revenue for Petrochina 2nd Campaign Nov,2017
- 20. Well Before Treatment, BBL AfterTreatment,BBL 9 Wells 0 - 5 TCC Clear 10 - 20BBL • Duri • Job treatment was to conduct wax/ inorganic treatment for 7 Wells. Well DelSolve Exo Act 1 Exo Act 2 7 Wells 15 (0.3BPM) 17 Drum (0.3BPM) 18 Drum (0.4BPM) • Micro-crystalline wax deposit • Predominantlyparaffinicin nature • High Pour Point • Cll : 2.98 • Dissolution Tested Meet Client KPI • Tubing clearance • Gain!! IDLE WELL REACTIVATION (INT)
- 21. Well Before Treatment, BBL AfterTreatment,BBL RID- 01 0 TCC Clear 300 BBL RID- 02 0 TCC Clear Pump Instalation RID- 05 0 TCC Clear Pump Instalation • Well not flowing foralmost 2 years for RID-01,02& RID-05 due to wax deposit build up at tubing, casing and perf zone Well Exo Act 1 Exo Act 2 RID-01 6 Drum (0.3BPM) 9 Drum (0.4BPM) RID-02 7 Drum (0.3BPM) 10 Drum (0.4BPM) RID-05 8 Drum (0.3BPM) 12 Drum (0.4BPM) • Macro-crystallinewax deposit • Cll : 0.92-1.73 • Water cut approx. at 35-40% Meet Client KPI • Gain % !! • 90 – 100% Wax Removed !!! IDLE WELL REACTIVATION (INT)
- 22. PREMIER OIL Well Before Treatment,BBL AfterTreatment, BBL A-18 200 TCC Clear 500 BBL A-19 90 TCC Clear 320 BBL • Natuna Sea Block well • Job treatment was to conduct wax/ inorganic treatment in the tubing for well candidateA19/A18 Well Exo Act 1 Exo Act 2 A-18 17 Drum (0.3BPM) 18 Drum (0.4BPM) A-19 25 Drum (0.3BPM) 27 Drum (0.4BPM) • Micro-crystalline wax deposit • Naphtenates 1.29% (High) • Cll : 1.32 • Dissolution Tested Meet Client KPI • Tubing clearance till SSD !! • DGL can be operated • Gain!!
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- 24. Open INJECTION OF CHEMICALSUSING MODULAR PUMPING TECHNIQUE Advantages: 1) Small and light weight 2) Quick deployment 3) Barge-less 4) Minimum crew requirement